US9120964B2 - Treatment fluids containing biodegradable chelating agents and methods for use thereof - Google Patents

Treatment fluids containing biodegradable chelating agents and methods for use thereof Download PDF

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US9120964B2
US9120964B2 US13/094,248 US201113094248A US9120964B2 US 9120964 B2 US9120964 B2 US 9120964B2 US 201113094248 A US201113094248 A US 201113094248A US 9120964 B2 US9120964 B2 US 9120964B2
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acid
treatment
treatment fluid
disuccinic
fluid
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US20120097392A1 (en
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Enrique A. Reyes
Thomas D. Welton
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Halliburton Energy Services Inc
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Halliburton Energy Services Inc
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Priority claimed from US11/499,447 external-priority patent/US8567504B2/en
Priority claimed from US13/051,827 external-priority patent/US9027647B2/en
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Priority to US13/094,248 priority Critical patent/US9120964B2/en
Assigned to HALLIBURTON ENERGY SERVICES, INC. reassignment HALLIBURTON ENERGY SERVICES, INC. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: REYES, ENRIQUE A., WELTON, THOMAS D.
Priority to US13/354,461 priority patent/US9127194B2/en
Priority to ARP120101410 priority patent/AR086041A1/es
Priority to CA2831490A priority patent/CA2831490C/en
Publication of US20120097392A1 publication Critical patent/US20120097392A1/en
Priority to EP12718713.6A priority patent/EP2702115A1/en
Priority to MX2013012402A priority patent/MX361872B/es
Priority to MYPI2013003586A priority patent/MY163333A/en
Priority to BR112013026091-2A priority patent/BR112013026091A2/pt
Priority to PCT/GB2012/000385 priority patent/WO2012146895A1/en
Priority to AU2012247281A priority patent/AU2012247281B2/en
Priority to MYPI2014001742A priority patent/MY165284A/en
Priority to US14/810,808 priority patent/US9745503B2/en
Publication of US9120964B2 publication Critical patent/US9120964B2/en
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    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/52—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
    • C09K8/528—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning inorganic depositions, e.g. sulfates or carbonates
    • C—CHEMISTRY; METALLURGY
    • C02—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
    • C02F—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
    • C02F5/00—Softening water; Preventing scale; Adding scale preventatives or scale removers to water, e.g. adding sequestering agents
    • C02F5/08—Treatment of water with complexing chemicals or other solubilising agents for softening, scale prevention or scale removal, e.g. adding sequestering agents
    • C02F5/10—Treatment of water with complexing chemicals or other solubilising agents for softening, scale prevention or scale removal, e.g. adding sequestering agents using organic substances
    • C02F5/12—Treatment of water with complexing chemicals or other solubilising agents for softening, scale prevention or scale removal, e.g. adding sequestering agents using organic substances containing nitrogen
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/60—Compositions for stimulating production by acting on the underground formation
    • C09K8/62—Compositions for forming crevices or fractures
    • C09K8/66—Compositions based on water or polar solvents
    • C09K8/68—Compositions based on water or polar solvents containing organic compounds
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/60—Compositions for stimulating production by acting on the underground formation
    • C09K8/62—Compositions for forming crevices or fractures
    • C09K8/72—Eroding chemicals, e.g. acids
    • C09K8/74—Eroding chemicals, e.g. acids combined with additives added for specific purposes
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/60—Compositions for stimulating production by acting on the underground formation
    • C09K8/62—Compositions for forming crevices or fractures
    • C09K8/72—Eroding chemicals, e.g. acids
    • C09K8/74—Eroding chemicals, e.g. acids combined with additives added for specific purposes
    • C09K8/78—Eroding chemicals, e.g. acids combined with additives added for specific purposes for preventing sealing
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/60—Compositions for stimulating production by acting on the underground formation
    • C09K8/84—Compositions based on water or polar solvents
    • C09K8/845—Compositions based on water or polar solvents containing inorganic compounds
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/60—Compositions for stimulating production by acting on the underground formation
    • C09K8/84—Compositions based on water or polar solvents
    • C09K8/86—Compositions based on water or polar solvents containing organic compounds
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02W—CLIMATE CHANGE MITIGATION TECHNOLOGIES RELATED TO WASTEWATER TREATMENT OR WASTE MANAGEMENT
    • Y02W10/00—Technologies for wastewater treatment
    • Y02W10/30—Wastewater or sewage treatment systems using renewable energies
    • Y02W10/37—Wastewater or sewage treatment systems using renewable energies using solar energy

Definitions

  • the present invention generally relates to treatment fluids containing chelating agents, and, more particularly, to treatment methods using treatment fluids that contain biodegradable chelating agents.
  • subterranean formations comprising acid-soluble components, such as those present in carbonate and sandstone formations
  • a treatment fluid comprising an acid to dissolve the formation matrix.
  • the treatment fluid and salts dissolved therein may be recovered by producing them to the surface (e.g., “flowing back” the well), leaving a desirable amount of voids or conductive pathways (e.g., wormholes in carbonates) within the formation.
  • Acidization can enhance the formation's permeability and may increase the rate at which hydrocarbons are subsequently produced from the formation.
  • Acidizing a siliceous formation should be distinguished from acidizing a carbonate formation.
  • Carbonate formations can be treated with a variety of acid systems, including mineral acids (e.g., hydrochloric acid), and organic acids (e.g., acetic and formic acids), often with similar success, where the acidity of the treatment fluid alone can be sufficient to solubilize formation cations.
  • the treatment of siliceous formations with these acids may have little or no effect because they do not react appreciably with the silica and silicates that characterize siliceous formations.
  • silica refers to the characteristic of having silica and/or silicate, including aluminosilicates.
  • Most sandstone formations are composed of about 40% to about 98% sand quartz particles, i.e., silica (SiO 2 ), bonded together by various amounts of cementing material including carbonate (calcite or CaCO 3 ), aluminosilicates, and silicates.
  • hydrofluoric acid is very reactive with aluminosilicates and silicates (e.g., sandstone, clays and feldspars).
  • Hydrochloric acid may be used in addition to hydrofluoric acid in the treatment fluid to maintain a low pH as hydrofluoric acid is spent during a treatment operation, thereby retaining certain dissolved species in a highly acidic solution. Hydrofluoric acid acidizing is often used to remove damage within the formation.
  • Such treatments are generally not considered “stimulating” in the sense of creating or extending fractures in the formation as in a typical fracturing operation.
  • a hydrofluoric acid treatment it is desirable that the skin value in the formation be zero. It is not anticipated that it will be less than zero. Any damage left behind gives a positive skin value, which is not desirable.
  • Hydrofluoric acid can interact with the formation matrix, base fluids, or formation fluids to create precipitates, particularly in the presence of metal ions such as Al 3+ , Fe 2+ , Group 1 metal ions (e.g., Na + and K + ) and/or Group 2 metal ions (e.g., Mg 2 ⁇ , Ca 2+ , and Ba 2+ ), thereby leading to further damage and a positive skin value.
  • metal ions such as Al 3+ , Fe 2+ , Group 1 metal ions (e.g., Na + and K + ) and/or Group 2 metal ions (e.g., Mg 2 ⁇ , Ca 2+ , and Ba 2+ ), thereby leading to further damage and a positive skin value.
  • metal ions such as Al 3+ , Fe 2+ , Group 1 metal ions (e.g., Na + and K + ) and/or Group 2 metal ions (e.g., Mg 2 ⁇ , Ca 2+ , and Ba 2+ )
  • the hydrofluoric acid may penetrate only a short distance into the formation before becoming spent.
  • precipitation of various aluminum and silicon complexes can occur as a result of the reaction of the acid with the siliceous minerals. Damage to the formation can result from this precipitation.
  • dissolution of a sandstone matrix or like siliceous material may occur so rapidly that uncontrolled precipitation can become an inevitable problem.
  • the precipitation products can plug pore spaces and reduce the porosity and permeability of the formation, thus impairing flow potential.
  • Remediation techniques include a commercially available treatment system from Halliburton Energy Services, Inc. known as “F-SOL” acid system, which can be used to dissolve calcium fluoride.
  • F-SOL fluoroaluminates
  • Another source of concern is the production of fluoroaluminates as a consequence of the reaction of fluorosilicates with clay minerals. Fluoroaluminates are thought to be soluble as long as the pH is below about 2 and the ratio of F/Al is maintained below about 2.5. If precipitated, their dissolution requires strong HCl (>5%).
  • Avoiding the formation of calcium fluoride, fluorosilicates, or other insoluble fluoro compounds can be a primary design objective in a treatment operation conducted in a subterranean formation or elsewhere.
  • Various means have been used with mixed success.
  • Blends of organic acids and hydrofluoric acid have been used to slow the dissolution kinetics of sandstone formation solids.
  • organic acids have higher pKa values than do mineral acids, precipitation can become problematic as the treatment fluid's pH rises.
  • Pre-flush sequences with acids have been used to remove calcium salts from sandstone formations, before the main acidizing sequence is conducted to remove formation aluminosilicates.
  • Chelating agents can also be included in treatment fluids to sequester at least a portion of the formation cations that cause unwanted precipitation.
  • many common chelating agents are not biodegradable or present other toxicity concerns that make their use in a subterranean formation problematic.
  • the salt form of some chelating agents can actually exacerbate precipitation problems in a hydrofluoric acid acidizing treatment rather than lessening the amount of precipitated solid.
  • chelating agents can be used in treating pipelines, tubing, and like vessels by removing metal ion scale from the pipeline or tubing surface. In such treatment operations, significant waste disposal issues can be encountered, since chelating agents that have commonly been used for such purposes are not biodegradable.
  • precipitation of formation cations in matrix acidizing operations can also be problematic, even when non-siliceous portions of a subterranean formation are being treated.
  • most formation cations can be dissolved with strong acid treatment fluids, dissolution of the formation matrix spends the acid. As the pH of the treatment fluid rises, certain cations can precipitate and damage the formation.
  • the use of very strong acids in a subterranean formation can lead to downhole corrosion issues, as previously mentioned. These issues can also be encountered when treating pipelines, tubing, and like vessels with an acidic fluid.
  • Sequestration of precipitatable cations in non-siliceous formations or in pipelines, tubing, or like vessels can likewise benefit from a chelating agent in much the same manner as that described above for siliceous formations by keeping the cation in a soluble state over a broad pH range.
  • the present invention generally relates to treatment fluids containing chelating agents, and, more particularly, to treatment methods using treatment fluids that contain biodegradable chelating agents.
  • the present invention provides a method comprising: providing a treatment fluid that comprises: an aqueous base fluid; and a chelating agent composition comprising at least one chelating agent selected from the group consisting of methylglycine diacetic acid, ⁇ -alanine diacetic acid, ethylenediaminedisuccinic acid, S,S-ethylenediaminedisuccinic acid, iminodisuccinic acid, hydroxyiminodisuccinic acid, polyamino disuccinic acids, N-bis[2-(1,2-dicarboxyethoxy)ethyl]glycine, N-bis[2-(1,2-dicarboxyethoxy)ethyl]aspartic acid, N-bis[2-(1,2-dicarboxyethoxy)ethyl]methylglycine, N-tris[(1,2-dicarboxyethoxy)ethyl]amine, N-methyliminodiacetic acid, iminodiacetic acid, N-(
  • the present invention provides a method comprising: providing a treatment fluid that comprises: an aqueous base fluid; and a chelating agent composition comprising at least one chelating agent selected from the group consisting of methylglycine diacetic acid, any salt thereof, any derivative thereof, and any combination thereof; and introducing the treatment fluid into at least a portion of a subterranean formation.
  • the present invention provides a method comprising: providing a treatment fluid that comprises: an aqueous base fluid; and a chelating agent composition comprising at least one chelating agent selected from the group consisting of glutamic acid diacetic acid, methylglycine diacetic acid, ⁇ -alanine diacetic acid, ethylenediaminedisuccinic acid, S,S-ethylenediaminedisuccinic acid, iminodisuccinic acid, hydroxyiminodisuccinic acid, polyamino disuccinic acids, N-bis[2-(1,2-dicarboxyethoxy)ethyl]glycine, N-bis[2-(1,2-dicarboxyethoxy)ethyl]aspartic acid, N-bis[2-(1,2-dicarboxyethoxy)ethyl]methylglycine, N-tris[(1,2-dicarboxyethoxy)ethyl]amine, N-methyliminodiacetic acid, im
  • FIGURE is included to illustrate certain aspects of the present invention, and should not be viewed as an exclusive embodiment.
  • the subject matter disclosed is capable of considerable modification, alteration, and equivalents in form and function, as will occur to those skilled in the art and having the benefit of this disclosure.
  • FIG. 1 shows a fractional pore volume effluent analysis.
  • the present invention generally relates to treatment fluids containing chelating agents, and, more particularly, to treatment methods using treatment fluids that contain biodegradable chelating agents.
  • compositions and methods of the present invention utilize biodegradable chelating agents that can be used in conjunction with hydrofluoric acid or other matrix acidizing treatments in subterranean formations that avoid many of the disadvantages associated with other chelating agents, including those discussed above.
  • biodegradable refers to a substance that can be broken down by exposure to environmental conditions including native or non-native microbes, sunlight, air, heat, and the like. Use of the term “biodegradable” does not imply a particular degree of biodegradability, mechanism or biodegradability, or a specified biodegradation half-life.
  • the biodegradable chelating agents are able to aid in the dissolution of metal cations, thereby assisting in the prevention or remediation of precipitates that can damage a formation or other surface.
  • the biodegradable chelating agents of the present invention can be used in an ammonium or tetraalkylammonium salt form, which has been surprisingly discovered to be particularly advantageous for hydrofluoric acid acidizing operations. Use of the ammonium or tetralkylammonium salt form can avoid the additional precipitation problems that can sometimes occur when other salt forms (e.g., alkali metal salts) are used in the context of this invention.
  • biodegradable chelating agents and methods of the present invention may be used in prevention embodiments to prevent the formation of precipitates in the presence of hydrofluoric acid, as discussed above, as well as remediation embodiments to remove damage in a well bore or subterranean formation.
  • GLDA glutamic acid diacetic acid
  • MGDA methylglycine diacetic acid
  • ⁇ -ADA ⁇ -alanine diacetic acid
  • EDDS ethylenediaminedisuccinic acid
  • IDS iminodisuccinic acid
  • HIDS hydroxyiminodisuccinic acid
  • BCA6 N-bis[2-(1,2-dicarboxyethoxy)ethyl]glycine
  • BCA5 N-bis[2-(1,2-dicarboxyethoxy)ethyl]aspartic acid
  • BCA5 N-bis[2-(1,2-dicarboxyethoxy)ethyl]methylglycine
  • MCBA5 N-tris[(1,2-dicarboxyethoxy)ethyl]amine
  • the treatment fluids of the present invention generally comprise an aqueous base fluid and at least one biodegradable chelating agent.
  • suitable biodegradable chelating agents can comprise GLDA, any GLDA salt, or any GLDA derivative.
  • suitable biodegradable chelating agents including MGDA, EDDS, IDS, HIDS, any salt thereof, any derivative thereof, or any combination thereof, including combinations with GLDA, can be used in the treatment fluids.
  • any of the previously listed biodegradable chelating agents can also be used in conjunction with the present invention. Particular advantages of some of these chelating agents are considered in more detail hereinafter.
  • salts other pH additives, corrosion inhibitors, surface active agents, anti-sludging agents, mutual solvents, scale inhibitors, viscosifiers, gases, diverting/fluid loss agents, and the like may be included in the treatment fluids of the present invention.
  • the present treatment fluids can be used in subterranean formations to prevent or remediate precipitation damage in the formation caused by the dissolution of formation cations, particularly in the presence of hydrofluoric acid.
  • the present treatment fluids can be used in treating pipes, tubing, and like vessels.
  • the base fluid of the present invention may comprise any aqueous or non-aqueous fluid.
  • the base fluid may comprise fresh water, salt water (e.g., water containing one or more salts dissolved therein), brine (e.g., saturated salt water), sea water, glycol, any combination thereof, or any derivative thereof.
  • the base fluid may comprise a liquid chelating agent or scale control agent by itself.
  • the base fluid may be from any source, provided that it does not contain components that might adversely affect the stability and/or performance of the treatment fluids of the present invention.
  • the chelating agent compositions of the present invention generally comprise a biodegradable chelating agent, any salt thereof, or any derivative thereof.
  • suitable derivatives of biodegradable chelating agents include esters and alkylated derivatives, for instance. Generally, any derivative can be used, provided that the derivative still maintains an affinity for binding metal cations.
  • suitable salts of the biodegradable chelating agents include sodium salts, rubidium salts, lithium salts, potassium salts, cesium salts, and ammonium salts, including tetraalkylammonium salts. Mixed salt forms can also be used, if desired.
  • GLDA is manufactured from a readily biodegradable, renewable, and human-consumable raw material, monosodium glutamate.
  • GLDA is readily soluble in high concentrations over a wide pH range.
  • GLDA is thought of as superior to many other chelating agents.
  • GLDA chelates metal ions such as, but not limited to, calcium, iron, aluminum, and magnesium over a wide pH range and is highly soluble in aqueous treatment fluids.
  • GLDA is commercially available in its sodium salt form.
  • Other salt forms may be available non-commercially, or in smaller quantities, or may be made through an ion-exchange technique discussed below.
  • the preferred form for use in conjunction with the embodiments described herein in which hydrofluoric acid or a hydrofluoric acid generating compound is used is not the monovalent metal salt form (i.e., an alkali metal salt), but rather an ammonium or tetraalkylammonium salt of GLDA.
  • a suitable commercial source of GLDA is a 47 wt. % aqueous solution from Akzo-Nobel Corp. available under the tradename “DISSOLVINE.”
  • MGDA is also commercially available in its sodium salt form.
  • a suitable commercial source of MGDA is a 40 wt. % aqueous solution of the sodium salt form, sold by BASF under the tradename “TRILON M.”
  • a sodium salt of GLDA, MGDA, or any other biodegradable chelating agent it may be desirable to exchange the sodium cations for other cations such as, for example, potassium, ammonium or tetraalkylammonium cations.
  • An ammonium or tetraalkylammonium salt is the preferred salt in the context of the present invention for treatment operations conducted in siliceous formations including, for example, clays and sandstones in which hydrofluoric acid or a hydrofluoric acid generating compound is used.
  • the potassium salt is preferred in some embodiments.
  • Exchange of the sodium cations for other cations can avoid precipitation of compounds such as, for example, NaHSiF 6 .
  • Cation exchange is contemplated to take place under conditions known to one of ordinary skill in the art.
  • Methods for exchanging sodium cations for potassium, ammonium, or tetraalkylammonium cations are contemplated to include, without limitation, ion exchange chromatography and selective precipitation techniques.
  • Other means for exchanging the sodium cations can be envisioned by one having ordinary skill in the art.
  • exchange of at least a portion of the sodium cations can produce better solubility properties and beneficially improve other operational characteristics of a treatment fluid containing GLDA or another biodegradable chelating agent of the present invention.
  • the pH window for clays is about 1 to about 6. In other embodiments, the pH window for clays is about 1.6 to about 4.5. In other embodiments, the pH window for clays is about 1.5 to about 1.8, and in other embodiments about 1.6 to about 3.
  • the treatment fluid has a pH ranging between about 1.5 and about 5, and in other embodiments, the treatment fluid has a pH ranging between about 1.5 and about 3. Particularly below these ranges, the biodegradable chelating agent may be ineffective for coordinating formation cations, as discussed below.
  • the pH of the treatment fluid may be about 5 to about 10.
  • a preferred pH range for carbonate formations may be 6 to about 9. The pH will be dependent on what purpose the chelating agent will serve downhole. A person having ordinary skill in the art with the benefit of this disclosure will be able to select the appropriate pH for a given application.
  • the pH for treating a pipe, tubing, or like vessel can range between about 5 and about 10. In other embodiments, the pH can range between about 5 and about 8 or between about 6 and about 8. In still other embodiments, the pH can be greater than about 8. It should be noted that at these higher pH values, the chelating agents will be significantly deprotonated and operable for chelating metal ions. For some applications such as, for example, the dissolution of barium scales, particularly in a pipe, tubing, or like vessel, high pH values such as about 8 or above or about 10 or above may be beneficial in this regard.
  • the acid dissociation constants of the chelating agent can dictate the pH range over which the treatment fluid can be most effectively used.
  • GLDA for instance, has a pK a value of about 2.6 for its most acidic carboxylic acid functionality. Below a pH value of about 2.6, dissolution of formation cations will be promoted primarily by the acidity of a treatment fluid containing GLDA, rather than by chelation, since the chelating agent will be in a fully protonated state.
  • MGDA in contrast, has a pK a value in the range of about 1.5 to 1.6 for its most acidic carboxylic acid group, and it will not become fully protonated until the pH is lowered to below about 1.5 to 1.6.
  • MGDA is particularly beneficial for use in acidic treatment fluids, since it extends the acidity range by nearly a full pH unit over which the chelating agent is an active chelant.
  • the lower pH of the treatment fluid beneficially allows for a more vigorous acidizing operation to take place.
  • the acid dissociation constant of EDDS (2.4) is comparable to that of GLDA.
  • biodegradable chelating agents described herein are currently available from commercial sources in bulk quantities with a reliable supply stream. From a supply standpoint, these biodegradable chelating agents are therefore preferred. For the reasons noted above, these chelating agents are operable over a different range of pH values, and they are complementary to one another in this respect. In addition to their pH complementarity, the biodegradable chelating agents described herein can have the capacity for selective chelate formation with different metal ions, both as an inherent function of the chelate stability constant and a kinetic/thermodynamic formation rate as a function of pH.
  • biodegradable chelating agents that are less readily available from commercial sources such as, for example, EDDS, ⁇ -ADA, IDS, and/or HIDS can be used singly or combined with GLDA or MGDA in order to “fine tune” the chelation properties of a treatment fluid.
  • Other combinations of biodegradable chelating agents can be considered as well.
  • Table 1 shows an illustrative listing of stability constants for various metal complexes of GLDA, MGDA, EDDS, IDS, HIDS, ⁇ -ADA and ethylenediaminetetraacetic acid (EDTA).
  • the ability of a given chelating agent to react with a given cation will be a function of the treatment fluid's pH. For instance, the maximum chelation of Fe(III) takes place at a pH of about 3 with MGDA and decreases at lower pH values. In contrast, the maximum chelation of Ca(II) and Mg(II) takes place at a higher pH with this chelating agent. Therefore, by adjusting the pH of the treatment fluid, its properties for binding a cation of interest can be altered.
  • a treatment fluid having a pH of about 3 or below can be used to selectively remove Fe(III) cations, while leaving Ca(II) and Mg(II) uncomplexed, thereby not wasting the chelating agent on cations whose chelation is unwanted.
  • the chelating agent composition comprises about 1% to about 50% by weight of the treatment fluid. In other embodiments, the chelating agent composition comprises about 3% to about 40% by weight of the treatment fluid. In some or other embodiments, the ratio of the chelating agent composition to water in a treatment fluid is about 1% to about 50% by weight based on a known or existing concentration. In some embodiments, the ratio of the chelating agent composition to water in a treatment fluid is about 1% to about 20% by weight based on a known or existing concentration. In some embodiments, this ratio may be about 3% to about 6%.
  • the treatment fluid can further comprise an acid.
  • the acid can be a mineral acid such as, for example, hydrochloric acid.
  • the acid can comprise hydrofluoric acid or a hydrofluoric acid generating compound.
  • the hydrofluoric acid in a treatment fluid of the present invention may be produced from a suitable hydrofluoric acid generating compound.
  • hydrofluoric acid generating compounds include, but are not limited to, fluoroboric acid, fluorosulfuric acid, hexafluorophosphoric acid, hexafluoroantimonic acid, difluorophosphoric acid, hexafluorosilicic acid, potassium hydrogen difluoride, sodium hydrogen difluoride, boron trifluoride acetic acid complex, boron trifluoride phosphoric acid complex, boron trifluoride dihydrate, polyvinylammonium fluoride, polyvinylpyridinium fluoride, pyridinium fluoride, imidazolium fluoride, ammonium fluoride, ammonium bifluoride, tetrafluoroborate salts, hexafluoroantimonate salts, hexafluorophosphate salts, bifluoride salts, and any combination thereof.
  • a hydrofluoric acid generating compound can be present in the treatment fluids in an amount ranging between about 0.1% to about 20% by weight of the treatment fluid. In other embodiments, an amount of the hydrofluoric acid generating compound can range between about 0.5% to about 10% or about 0.5% to about 8% by weight of the treatment fluid.
  • the treatment fluids of the present invention may also include a viscoelastic surfactant.
  • a viscoelastic surfactant any suitable surfactant that is capable of imparting viscoelastic properties to an aqueous fluid may be used in accordance with the teachings of the present invention.
  • These surfactants may be cationic, anionic, nonionic, zwitterionic or amphoteric in nature, and comprise any number of different compounds, including methyl ester sulfonates (such as those described in commonly owned U.S. Pat. Nos. 7,159,659, 7,299,874, and 7,303,019 and U.S. patent application Ser. No. 11/058,611, filed Feb.
  • the surfactant is generally present in an amount sufficient to provide a desired viscosity (e.g., sufficient viscosity to divert flow, reduce fluid loss, suspend particulates, and the like) through the formation of viscosifying micelles.
  • the surfactant generally comprises from about 0.5% to about 10%, by volume, of the treatment fluid. In more particular embodiments, the surfactant comprises from about 1% to about 5%, by volume, of the treatment fluid.
  • the treatment fluids of the present invention may also comprise one or more cosurfactants to, among other things, facilitate the formation of and/or stabilize a foam, facilitate the formation of micelles (e.g., viscosifying micelles), increase salt tolerability, and/or stabilize the treatment fluid.
  • the cosurfactant may comprise any surfactant suitable for use in subterranean environments that does not adversely affect the treatment fluid.
  • cosurfactants suitable for use in the present invention include, but are not limited to, linear C 10 -C 14 alkyl benzene sulfonates, branched C 10 -C 14 alkyl benzene sulfonates, tallow alkyl sulfonates, coconut alkyl glyceryl ether sulfonates, sulfated condensation products of mixed C 10 -C 18 tallow alcohols with about 1 to about 14 moles of ethylene oxide, and mixtures of higher fatty acids containing about 10 to about 18 carbon atoms.
  • the cosurfactant may be present in an amount in the range of from about 0.05% to about 5% by volume of the treatment fluid.
  • the cosurfactant may be present in an amount in the range of from about 0.25% to about 0.5% by volume of the treatment fluid.
  • the type and amount of cosurfactant suitable for a particular application of the present invention may depend upon a variety of factors, such as the type of surfactant present in the treatment fluid, the composition of the treatment fluid, the temperature of the treatment fluid, and the like. A person of ordinary skill in the art, with the benefit of this disclosure, will recognize when to include a cosurfactant in a particular application of the present invention, as well as the appropriate type and amount of cosurfactant to include.
  • the treatment fluids of the present invention may optionally comprise one or more salts to modify the rheological properties (e.g., viscosity) of the treatment fluids.
  • These salts may be organic or inorganic.
  • suitable organic salts include, but are not limited to, aromatic sulfonates and carboxylates (e.g., p-toluenesulfonate and napthalenesulfonate), hydroxynapthalene carboxylates, salicylates, phthalates, chlorobenzoic acid, phthalic acid, 5-hydroxy-1-naphthoic acid, 6-hydroxy-1-naphthoic acid, 7-hydroxy-1-naphthoic acid, 1-hydroxy-2-naphthoic acid, 3-hydroxy-2-naphthoic acid, 5-hydroxy-2-naphthoic acid, 7-hydroxy-2-naphthoic acid, 1,3-dihydroxy-2-na
  • suitable inorganic salts include water-soluble potassium, sodium, and ammonium salts (e.g., potassium chloride and ammonium chloride). Any combination of the salts listed above also may be included in the treatment fluids of the present invention. Where included, the one or more salts may be present in an amount ranging between about 0.1% to about 75% by weight of the treatment fluid. In more particular embodiments, the one or more salts may be present in an amount ranging from about 0.1% to about 10% by weight of the treatment fluid.
  • a salt in a particular application of the present invention, as well as the appropriate type and amount of salt to include.
  • the treatment fluids of the present invention may also include one or more well-known additives, such as gel stabilizers, fluid loss control additives, particulates, acids, corrosion inhibitors, catalysts, clay stabilizers, biocides, friction reducers, additional surfactants, solubilizers, pH adjusting agents, bridging agents, dispersants, flocculants, foamers, gases, defoamers, H 2 S scavengers, CO 2 scavengers, oxygen scavengers, scale inhibitors, lubricants, viscosifiers, weighting agents, and the like.
  • additives such as gel stabilizers, fluid loss control additives, particulates, acids, corrosion inhibitors, catalysts, clay stabilizers, biocides, friction reducers, additional surfactants, solubilizers, pH adjusting agents, bridging agents, dispersants, flocculants, foamers, gases, defoamers, H 2 S scavengers, CO 2 scavengers
  • methods described herein comprise providing a treatment fluid that comprises an aqueous base fluid, hydrofluoric acid or a hydrofluoric acid generating compound, and a chelating agent composition comprising glutamic acid diacetic acid, any salt thereof, or any derivative thereof, and introducing the treatment fluid into at least a portion of a subterranean formation.
  • the treatment fluid may remove potentially damaging precipitates from the formation, for example.
  • Any other biodegradable chelating agent described herein can also be used in combination with or in place of the GLDA.
  • treatment fluids comprising an aqueous base fluid and a chelating agent composition comprising glutamic acid diacetic acid, any salt thereof, or any derivative thereof are described herein.
  • methods described herein comprise providing a treatment fluid that comprises an aqueous base fluid and a chelating agent composition comprising glutamic acid diacetic acid, any salt thereof, or any derivative thereof, and introducing the treatment fluid into at least a portion of a subterranean formation.
  • a chelating agent composition comprising glutamic acid diacetic acid, any salt thereof, or any derivative thereof.
  • Any other biodegradable chelating agent described herein can also be used in combination with or in place of the GLDA.
  • methods described herein comprise providing a treatment fluid that comprises an aqueous base fluid and a chelating agent composition comprising at least one chelating agent selected from methylglycine diacetic acid, ⁇ -alanine diacetic acid, ethylenediaminedisuccinic acid, S,S-ethylenediaminedisuccinic acid, iminodisuccinic acid, hydroxyiminodisuccinic acid, polyamino disuccinic acids, N-bis[2-(1,2-dicarboxyethoxy)ethyl]glycine, N-bis[2-(1,2-dicarboxyethoxy)ethyl]aspartic acid, N-bis[2-(1,2-dicarboxyethoxy)ethyl]methylglycine, N-tris[(1,2-dicarboxyethoxy)ethyl]amine, N-methyliminodiacetic acid, iminodiacetic acid, N-(2-acetamido)iminodiac
  • methods described herein comprise providing a treatment fluid that comprises an aqueous base fluid and a chelating agent composition comprising at least one chelating agent selected from methylglycine diacetic acid, any salt thereof, any derivative thereof, and any combination thereof; and introducing the treatment fluid into at least a portion of a subterranean formation.
  • the treatment fluid can further comprise hydrofluoric acid or a hydrofluoric acid generating compound.
  • the chelating agent composition can be substantially free of alkali metal ions and comprise an ammonium or tetraalkylammonium salt of the biodegradable chelating agent.
  • other biodegradable chelating agents described herein can be used in combination with methylglycine diacetic acid.
  • methods described herein comprise providing a treatment fluid that comprises an aqueous base fluid and a chelating agent composition comprising at least one chelating agent selected from glutamic acid diacetic acid, methylglycine diacetic acid, ⁇ -alanine diacetic acid, ethylenediaminedisuccinic acid, S,S-ethylenediaminedisuccinic acid, iminodisuccinic acid, hydroxyiminodisuccinic acid, polyamino disuccinic acids, N-bis[2-(1,2-dicarboxyethoxy)ethyl]glycine, N-bis[2-(1,2-dicarboxyethoxy)ethyl]aspartic acid, N-bis[2-(1,2-dicarboxyethoxy)ethyl]methylglycine, N-tris[(1,2-dicarboxyethoxy)ethyl]amine, N-methyliminodiacetic acid, iminodiacetic acid, N-(2-ace
  • treating a pipe or tubing with the treatment fluid can comprise removing metal ion scale from the pipe or tubing.
  • the pipe can comprise a well bore penetrating at least a portion of a subterranean formation.
  • the treatment fluid can have a pH ranging between about 6 and about 8. In other embodiments, the treatment fluid can have a pH of at least about 8.
  • an acidic treatment fluid of the present invention that comprises an aqueous base fluid, hydrofluoric acid or a hydrofluoric acid generating compound, and a biodegradable chelating agent composition that comprises glutamic acid diacetic acid, any glutamic acid diacetic acid salt, or any glutamic acid diacetic acid derivative can be used in prevention methods to prevent the formation of precipitates such as, for example, those produced in conjunction with a hydrofluoric acid treatment in a sandstone formation.
  • These embodiments are most appropriate for formations that comprise clays or include cations that can be problematic in terms of precipitate formation.
  • biodegradable chelating agents such as, for example MGDA, ⁇ -ADA, EDDS, IDS, HIDS, any salt thereof, any derivative thereof, any combination thereof, or any other biodegradable chelating agent described herein can be used in place of or in combination with GLDA, any GLDA salt, or any GLDA derivative.
  • the hydrofluoric acid or hydrofluoric acid generating compound can be omitted from the treatment fluid, particularly if the subterranean formation being treated is not a sandstone or like siliceous formation.
  • the treatment fluids of the present invention may be used as a pre-treatment to a fracturing treatment, especially in subterranean formations that contain different layers of sedimentary rock.
  • a treatment fluid of the present invention comprising an aqueous base fluid, hydrofluoric acid or a hydrofluoric acid generating compound, and a chelating agent composition of the present invention that comprises glutamic acid diacetic acid, any glutamic acid diacetic acid salt, or any glutamic acid diacetic acid derivative is placed in a subterranean formation via a well bore before a fracturing treatment.
  • the subsequent fracturing treatment can be a traditional fracturing treatment or an additional acidizing treatment directed at treating the particulate pack introduced during the fracturing operation.
  • the use of the treatment fluid of the present invention may be considered a prevention mechanism to prevent the formation of potentially problematic precipitates.
  • other biodegradable chelating agents such as, for example MGDA, ⁇ -ADA, EDDS, IDS, HIDS, any salt thereof, any derivative thereof, combinations thereof, or any other biodegradable chelating agent described herein can be used in place of or in combination with GLDA, any GLDA salt, or any GLDA derivative, and the hydrofluoric acid or hydrofluoric acid generating compound can be optionally omitted.
  • a treatment fluid of the present invention comprising an aqueous base fluid, hydrofluoric acid or a hydrofluoric acid generating compound, and a chelating agent composition of the present invention that comprises glutamic acid diacetic acid, any glutamic acid diacetic acid salt, or any glutamic acid diacetic acid derivative may be used to clean the well bore area before bringing the well into final production.
  • a treatment fluid can remove damage, blockages, debris, and natural clays in the formation, for example.
  • this method may be considered a remediation method of the present invention.
  • biodegradable chelating agents such as, for example MGDA, ⁇ -ADA, EDDS, IDS, HIDS, any salt thereof, any derivative thereof, any combination thereof, or any other biodegradable chelating agent described herein can be used in place of or in combination with GLDA, any GLDA salt, or any GLDA derivative, and the hydrofluoric acid or hydrofluoric acid generating compound can be optionally omitted.
  • the treatment fluids of the present invention may be useful in formations that comprise siliceous materials, for example, naturally occurring sandstone, propping material, etc.
  • a siliceous material can be naturally present in the formation, e.g., the sandstone, or deliberately introduced, e.g., a quartz proppant. Due to the geochemical processes operative in the formation, such as high temperature, high pressure, and abrupt changes to the geochemical balance after the introduction of treatment fluids of different ionic strength, the siliceous material can undergo rapid changes that lead to reduction of permeability or hydraulic conductivity. When the treatment is carried out in the matrix of the sandstone, the effect is believed to remove aluminosilicates from the conductive pathways.
  • the treatment fluid may not include hydrofluoric acid or a hydrofluoric acid generating compound.
  • Glutamic acid diacetic acid, any glutamic acid diacetic acid salt, any glutamic acid diacetic acid derivative or any of the alternative biodegradable chelating agents described herein, or any of their salts or derivatives described herein may be sufficient to perform the desired preventive action.
  • it may be desirable to remediate precipitate damage present in the well bore or in the formation that may be blocking pore throats within the formation. Such methods may be appropriate any time where production has declined due to the presence of particulates or fines that obstruct pore throats in the near well bore area.
  • an additional acid can be included in the treatment fluid.
  • the additional acid can be a mineral acid such as, for example, hydrochloric acid, which may be included in the treatment fluid with hydrofluoric acid or a hydrofluoric acid generating compound.
  • the additional acid can be an organic acid such as, for example, chloroacetic acid, dichloroacetic acid, trichloroacetic acid, or methanesulfonic acid. In either case, the additional acid can serve to keep the pH of the fluid at a desired low level, particularly a level at which the chelating agent is active for chelation to occur.
  • a salt or a salt substitute in the treatment fluid.
  • the beneficial effects of a salt or salt substitute are surprising, since it is conventionally believed that adding a salt to a treatment fluid can exacerbate precipitation problems.
  • a preferred example of a suitable salt is ammonium chloride or like ammonium salt. It is believed that this is a problem specific to treatment fluids containing hydrofluoric acid or a hydrofluoric acid generating compound, since alkali metal salts such as sodium and potassium salts can promote the formation of precipitates in the presence of fluoride ions. In contrast, adding an ammonium salt will not exacerbate the precipitation problem.
  • the treatment fluids of the present invention may be used to treat a proppant pack, particularly where the proppant pack's hydraulic conductivity has been impacted.
  • a solution of DISSOLVINE® (GLNA40S) available from AkzoNobel was used in the preparation of the treatment fluid.
  • a solution containing 3.5 wt. % of GLNA40S was prepared by dissolving 363.5 g of concentrated form into a base fluid.
  • the base fluid consisted of 2% NaCl containing 20 g/L of tannic acid.
  • the pH of the final volume of solution (4 L) was adjusted to pH 1.6 with 35% HCl.
  • the solution was filtered through a 0.40 micron membrane. It was stable for the duration of the testing period (days).
  • a 2′′ ⁇ 12′′ long Hassler sleeve was employed to conduct a core flood acid test at 320° F.
  • the sleeve was packed with a homogenized mixture of quartz (Oklahoma #1 sand) (94 wt. %), K-feldspar (2 wt. %), and the aluminosilicate chlorite (4 wt. %).
  • the pore volume (PV) of the packed column corresponded to 110 mL.
  • the column was treated with the following fluid sequence:
  • the results of the core flood indicated that during the 2 PV of DISSOLVINE® (GLNA40S) exposure, indicated on FIG. 1 by the arrow spanning samples 4-12, the amount of Al 3+ , as detected by ICP-OES, increase gradually until the chelating agent injection was stopped. Once the sand/chlorite pack was no longer exposed to the chelating fluid the aluminum released into solution ceased.
  • the flow rate was 2 mL/min throughout the first 1.5 PV and then increased to 5 mL/min during the last 0.5 PV.
  • the effluent was collected at intervals of 0.5 and 1 PV analyzed for Al 3+ and Si 4+ by ICP, no quantitative precipitates were observed in the effluent which was stable for days at room temperature after collection.
  • the respective effluent samples collected for ICP analysis were not acidified with any additional acid, rather they were analyzed in their respective pH at collection time. The amount of silicon remained nearly constant.
  • a glass vial containing 5 g of mineral (clay or quartz) was mixed with 15 or 20 mL of treatment fluid.
  • the treatment fluid was composed of GLDA 15 wt. % and 3 wt. % NH 4 HF 2 with sufficient HCl to adjust the pH to the indicated value in Table 2 below.
  • the reaction mixtures were heated in a heated cylinder to 95° C. for 0.5, 1, 2, 3, 4 hours and automatically shaken (at 200 rpm).
  • the reaction fluid was collected via a syringe and filtrated through a 0.45 micron membrane filter prior to ICP-AES analysis, the pH of the solution was not adjusted via any means.
  • the elemental analysis for each mineral is provided in Table 2.
  • compositions and methods are described in terms of “comprising,” “containing,” or “including” various components or steps, the compositions and methods can also “consist essentially of” or “consist of” the various components and steps. All numbers and ranges disclosed above may vary by some amount. Whenever a numerical range with a lower limit and an upper limit is disclosed, any number and any included range falling within the range is specifically disclosed. In particular, every range of values (of the form, “from about a to about b,” or, equivalently, “from approximately a to b,” or, equivalently, “from approximately a-b”) disclosed herein is to be understood to set forth every number and range encompassed within the broader range of values.

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BR112013026091-2A BR112013026091A2 (pt) 2011-04-26 2012-04-26 método de tratamento subterrâneo
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US20120097392A1 (en) 2012-04-26
WO2012146895A1 (en) 2012-11-01
MX2013012402A (es) 2014-11-21
CA2831490C (en) 2016-01-26

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